Plasticized Polyvinyl Alcohol Diverter Materials

ABSTRACT

Methods for treating subterranean formations by diverting treatment fluids therein are provided. In one embodiment, the methods comprise: introducing a first diverter material comprising polyvinyl alcohol and a plasticizer into or adjacent to a permeable zone of a subterranean formation; introducing a second diverter material into or adjacent to the permeable zone of the subterranean formation, wherein at least a portion of the first diverter material comprises particles larger than particles of the second diverter material; and allowing the first diverter material and the second diverter material to at least partially divert at least a portion of a treatment fluid to a different portion of the subterranean formation.

BACKGROUND

The present disclosure relates to methods for treating subterraneanformations by diverting treatment fluids therein. Diverting agents maybe used in a variety of subterranean treatments. Such treatmentsinclude, but are not limited to, drilling, stimulation treatments (e.g.,fracturing treatments, matrix acidizing treatments), and cementingoperations. To ensure the producing zone is contacted by the treatingfluid uniformly, a solid diverting agent may be placed in the zone todirect the placement of a desired treatment fluid. The term “zone,” asused herein, simply refers to a portion of the formation and does notimply a particular geological strata or composition. One technique hasbeen to pack the diverting agent in perforation tunnels extending fromthe wellbore into the subterranean zone. The diverting agent in theperforation tunnels causes the treating fluid introduced therein to beuniformly distributed between all of the perforations whereby thesubterranean zone is uniformly treated.

For example, in acid stimulation operations, it may be desired tocontact less permeable portions of the subterranean formation with thetreatment fluid containing an acid so as to achieve the desiredstimulation. In other instances, it might be desired to divert atreatment fluid away from certain portions (e.g., water-producingportions) of a subterranean formation entirely so as to treat otherportions (e.g., hydrocarbon-producing portions) of the subterraneanformation. In scale inhibition operations and clay stabilizationoperations, it may be desirable to divert the treatment fluid so as toobtain a uniform distribution of the treatment fluid throughout thesubterranean formation regardless of the permeability of the particularportion thereof.

Traditional examples of particulate diverting agents are inorganicmaterials such as rock salts and polymeric materials such as starch,polyesters, and the like. Existing means for diverting treatment fluidsfor near wellbore (NWB) and far field stimulation applications oftencomprise polylactic acid, which may be costly and logisticallychallenging due to storage concerns in high temperature conditions.Additionally, degradation of polylactic acid diverter materials may beless effective at downhole temperatures below 140° F. and thedegradation products of polylactic acid are acidic, which may corrodeequipment.

BRIEF DESCRIPTION OF THE FIGURES

These figures illustrate certain aspects of some of the embodiments ofthe present disclosure, and should not be used to limit or define theclaims.

FIG. 1 is a diagram illustrating an example of a system that may be usedin accordance with certain embodiments of the present disclosure.

FIG. 2 is a diagram illustrating an example of a subterranean formationpenetrated by a wellbore in which a treatment fluid may be diverted fromone permeable zone to another permeable zone using a diverter materialof the present disclosure.

FIG. 3 is a graph illustrating data regarding flow rate and pressureversus time for the simulation of a composition plugging a loss zone inaccordance with certain embodiments of the present disclosure.

FIG. 4 is a plot illustrating data regarding flow rate and pressureversus time for the simulation of a composition plugging a loss zone inaccordance with certain embodiments of the present disclosure.

While embodiments of this disclosure have been depicted, suchembodiments do not imply a limitation on the disclosure, and no suchlimitation should be inferred. The subject matter disclosed is capableof considerable modification, alteration, and equivalents in form andfunction, as will occur to those skilled in the pertinent art and havingthe benefit of this disclosure. The depicted and described embodimentsof this disclosure are examples only, and not exhaustive of the scope ofthe disclosure.

DESCRIPTION OF CERTAIN EMBODIMENTS

Illustrative embodiments of the present disclosure are described indetail herein. In the interest of clarity, not all features of an actualimplementation may be described in this specification. It will of coursebe appreciated that in the development of any such actual embodiment,numerous implementation-specific decisions may be made to achieve thespecific implementation goals, which may vary from one implementation toanother. Moreover, it will be appreciated that such a development effortmight be complex and time-consuming, but would nevertheless be a routineundertaking for those of ordinary skill in the art having the benefit ofthe present disclosure.

As used herein, the terms “treat,” “treatment,” “treating,” andgrammatical equivalents thereof refer to any subterranean operation thatuses a fluid in conjunction with achieving a desired function and/or fora desired purpose. Use of these terms does not imply any particularaction by the treatment fluid. Illustrative treatment operations caninclude, for example, fracturing operations, gravel packing operations,acidizing operations, scale dissolution and removal, consolidationoperations, and the like.

As used herein, references to particle sizes of a particular mesh “orlarger” and grammatical equivalents thereof refers to particles of thatparticular mesh size and particles larger than that size. Similarly, asused herein, references to sizes of a particular mesh “or smaller” andgrammatical equivalents thereof refers to particles of that particularmesh size and particles smaller than that size.

The present disclosure relates to methods for treating subterraneanformations by diverting treatment fluids therein. More particularly, thepresent disclosure relates to methods for diverting treatment fluids toless permeable zones of subterranean formations using a divertermaterial comprising a plasticizer and polyvinyl alcohol. As used herein,the term “plasticized PVA diverter material” refers to a composite ormixed material comprising polyvinyl alcohol (“PVA”) and a plasticizer.As used herein, the term “permeable zone” refers to a distinct part of awellbore designated for treatment and/or production that can bepermeated or penetrated by liquids or gases, including, but not limitedto, fractures and fissures in the subterranean formation, both naturallyoccurring and artificially created.

The present disclosure provides methods comprising introducing a firstdiverter material comprising polyvinyl alcohol and a plasticizer into oradjacent to a permeable zone of a subterranean formation; introducing asecond diverter material into or adjacent to the permeable zone of thesubterranean formation, wherein at least a portion of the first divertermaterial comprises particles larger than particles of the seconddiverter material; and allowing the first diverter material and thesecond diverter material to at least partially divert at least a portionof a treatment fluid to a different portion of the subterraneanformation. In some embodiments, the first diverter material may comprisea plasticized PVA diverter material. In certain embodiments, the firstdiverter material comprises particles sized 6 U.S. mesh or larger. Incertain embodiments, the second diverter material comprises particlessized 8 U.S. mesh or smaller. In some embodiments, a second divertermaterial may be introduced into or adjacent to the permeable zone of thesubterranean formation. The second diverter material may be introducedprior to, concurrently with, or subsequent to the introduction of thefirst diverter material. In some embodiments, additional divertermaterials may be introduced. In certain embodiments, the divertermaterials may comprise combinations of two or more materials. Thediverter material may be combined with a carrier fluid (e.g., an aqueousbase fluid) before being introduced into the subterranean formation. Inthe methods of the present disclosure, the diverter materials of thepresent disclosure may be introduced into or adjacent to at least aportion of a permeable zone of a subterranean formation. A treatmentfluid may then be introduced into the subterranean formation and may bediverted away from the permeable zone by the diverter material to a lesspermeable zone of the subterranean formation. In some embodiments, asecond diverter material may be introduced. In certain embodiments, thefirst and/or second diverter materials may degrade or dissolve over timeafter diverting the treatment fluid.

In some embodiments, the present disclosure provides methods ofintroducing a first treatment fluid comprising an aqueous base fluid anda first diverter material comprising polyvinyl alcohol and a plasticizerinto or adjacent to a permeable zone of a subterranean formation,wherein the first diverter material comprises particles sized 6 U.S.mesh or larger; and allowing the first treatment fluid to at leastpartially divert at least a portion of a second treatment fluid to adifferent portion of the subterranean formation. In certain embodiments,the present disclosure provides methods of introducing a first divertercomposition into or adjacent to a permeable zone of a subterraneanformation, wherein the first diverter composition comprises: a firstdiverter material comprising polyvinyl alcohol and a plasticizer,wherein the first diverter material comprises particles sized 6 U.S.mesh or larger; and a second diverter material comprising particlessized 8 U.S. mesh or smaller; and allowing the diverter composition toat least partially divert at least a portion of a treatment fluid to adifferent portion of the subterranean formation.

Among the many potential advantages to the methods of the presentdisclosure, only some of which are alluded to herein, the methods of thepresent disclosure may allow for more effective diversion of treatmentfluids by providing improved diversion, degradation, and/or dissolutionperformance. In some embodiments, and without being bound by theory, theplasticizer of the present disclosure may allow for larger PVA particlesto be formed. In certain embodiments, the plasticized PVA divertermaterial may swell, allowing for reduced material usage to achieve thesame diversion as a non-swellable diverting agent. The plasticized PVAdiverter material may dissolve effectively at temperatures of 110° F. orlower, even as low as room temperature. Additionally, in someembodiments, the dissolution products of the plasticized PVA divertermaterial may be around neutral pH, which may mitigate or avoid certainissues caused by acid-releasing degradable materials used as divertingmaterials. In certain embodiments, the methods of the present disclosuremay permit a plasticized PVA diverter material used to divert atreatment fluid to degrade or dissolve under naturally-occurringconditions of the subterranean formation, and may thus eliminate theneed to introduce agents that accelerate the dissolution or degradationprocess into the subterranean formation.

The plasticized PVA diverter material of the present disclosure maycomprise polyvinyl alcohol and a plasticizer. In certain embodiments,the plasticized PVA diverter material is a composite material comprisingthe PVA and the plasticizer. In certain embodiments, the compositematerial may comprise additional additives. In certain embodiments, thecomposite material may consist essentially of PVA and a plasticizer. Insome embodiments, the plasticized PVA diverter material may be a solidupon introduction into the wellbore, subterranean formation, and/orpermeable zone. In some embodiments, the plasticized PVA divertermaterial is a solid when it is combined with a treatment fluid prior tointroduction to the subterranean formation.

Without being limited by theory, the plasticizer of the plasticized PVAdiverter material may stabilize the PVA in the diverter material. Incertain embodiments, the plasticizer may reduce the melting point of PVAbelow its degradation point, allowing for the PVA to be liquefied andprocessed through an extruder to form larger particles of PVA than ispossible without the plasticizer. In some embodiments, the plasticizermay be a surfactant. Plasticizers suitable for certain embodiments ofthe present disclosure may include, but are not limited to glycol,polyethylene glycol, polypropylene glycol, fatty acid esters, lactidemonomers, glycolide monomers, citric acid esters, epoxidized oil,adipate ester, azaleate ester, acetylated coconut oil, and anycombination thereof. In some embodiments, the plasticizer may bepolyethylene glycol with a molecular weight of from about 2 to about1200. In some embodiments, the plasticizer may be hydrophobic orhydrophilic. In some embodiments, the plasticizer may be water soluble.In certain embodiments, the plasticizer is not water soluble.

The plasticizer may be present in the plasticized PVA diverter materialin an amount sufficient to allow PVA to be extruded and processed toyield larger particles, for example particles sized 4 mesh (U.S. SieveSeries). In some embodiments, the concentration of the plasticizer inthe plasticized PVA diverter material may be tuned to affect thedissolution or degradation rate of the plasticized PVA divertermaterial. In certain embodiments, the plasticizer may be present in anamount of from about 0.1 wt % to about 50 wt % by weight of theplasticized PVA diverter material. In some embodiments, the plasticizermay be present in amount greater than 1 wt %, 5 wt %, 10 wt %, 15 wt %,20 wt %, 25 wt %, 30 wt %, 35 wt %, 40 wt %, or 45 wt % by weight of theplasticized PVA diverter material. In some embodiments, the plasticizermay be present in an amount of from about 1 wt % to about 30 wt %, fromabout 5 wt % to about 20 wt %, from about 10 wt % to about 30 wt %, fromabout 15 wt % to about 30 wt %, all by weight of the plasticized PVAdiverter material.

In certain embodiments, the plasticized PVA diverter material (and/orother material with which it is mixed) may be sized to bridge the porethroats, microfractures, or other spaces of a particular region of asubterranean formation, among other reasons, to reduce or prevent fluidloss into the formation matrix and/or to divert the flow of fluid toother (e.g., less permeable) regions of the formation. In certainembodiments, diverter materials of the present disclosure may haveparticle sizes in a particular range or in several discrete ranges(e.g., as a multimodal material). The plasticized PVA diverter materialmay have a broad particle size distribution or a narrow particle sizedistribution. The selection of a suitable particle size distribution forthe plasticized PVA diverter material may depend on factors such as thepermeability of the formation, the type of formation, the extent of theangle between the natural fractures and manmade fractures therein, andthe like. For example, in certain embodiments, the size and/or diameterof the plasticized PVA diverter material may be tailored for aparticular application based on, for example, the size of one or morepore throats or fracture width within a subterranean formation in whichthe plasticized PVA diverter material are to be used, as well as otherfactors.

In certain embodiments, the plasticized PVA diverter material maycomprise particles, an amorphous or other non-particulate material, or acombination thereof. In certain embodiments, the plasticized PVAdiverter material and/or plasticized PVA diverter particles may be ofany shape (regular or irregular) suitable for a particular application.In some embodiments, the plasticized PVA diverter material (and/or otherparticulate material with which it is mixed) may have any shape,including, but not limited to, particles having the physical shape ofplatelets, shavings, flakes, ribbons, rods, strips, spheroids, toroids,stars, sheets, cylinders, beads, cylindrical beads, cubes, pellets,tablets, any other physical shape, and any combination thereof. One ofordinary skill in the art, with the benefit of this disclosure, willrecognize the suitable sizes and shapes of the plasticized PVA divertermaterial for a given application of the present disclosure. In certainembodiments, the aspect ratio of the plasticized PVA diverter materialmay be about 5:1, 10:1, or 20:1. In some embodiments, the first divertermaterial may have an aspect ratio of about 20:1 or less, about 10:1 orless, or about 5:1 or less.

In some embodiments, the plasticized PVA diverter material may have aparticle size of U.S. mesh size 6 or larger. In some embodiments, theplasticized PVA diverter material may have a particle size of U.S. meshsize 2 or larger. Although some embodiments include no limit to theplasticized PVA diverter material particle size, other embodiments mayinclude a lower size limit or an upper size limit. A lower limit of thesize of plasticized PVA diverter material particles according to certainembodiments may be any one of: 80, 70, 60, 50, 40, 35, 30, 25, 20, 18,16, 14, 12, 10, 8, 7, 6, 5, 4, 3, and 2 U.S. mesh size. In certainembodiments, the plasticized PVA diverter material may have a particlesize distribution in the range of about 4 to 6 U.S. mesh; about 2 to 4U.S. mesh; about 2 to 6 U.S. mesh; about 2 to 8 U.S. mesh; about 2 to 10U.S. mesh; about 4 to 8 U.S. mesh; about 4 to 10 U.S. mesh; and about 4to about 12 U.S. mesh. In certain embodiments, the plasticized PVAdiverter material may have a particle size of from about 1 mm to about6.5 mm. In certain embodiments, the plasticized PVA diverter materialmay have a particle size of about 4 U.S. mesh or larger. One of ordinaryskill in the art, with the benefit of this disclosure, will be able toidentify a suitable particle size distribution for the plasticized PVAdiverter material for a particular application.

In certain embodiments, the particles of the plasticized PVA divertermaterial may be sized so that the plasticized PVA diverter material willnot enter the matrix or pore spaces of the rock present in asubterranean formation. In certain embodiments, the particles of theplasticized PVA diverter material may be sized so that the plasticizedPVA diverter material will enter microfractures, fractures and fissures,both naturally occurring and artificially created, within the permeablezone.

In some embodiments, the plasticized PVA diverter material of thepresent disclosure may absorb an aqueous solution and swell (i.e.,expand) as it absorbs the aqueous solution. In certain embodiments, theplasticized PVA diverter material may be hydrophilic and thus may bephysically attracted to water molecules. For example, in certainembodiments, the plasticized PVA diverter material may be contacted withan aqueous fluid and may swell as it absorbs the aqueous fluid. Incertain embodiments, as the plasticized PVA diverter material undergoeshydration, its volume may increase by about 10 times to about 400 timesits original volume. As would be appreciated by those of ordinary skillin the art with the benefit of this disclosure, the amount and rate bywhich the plasticized PVA diverter material increases in volume may varydepending upon its size, the temperature on the surface, the temperatureof the subterranean formation, and the ionic strength of a carrier fluidused to introduce the plasticized PVA diverter material into asubterranean formation. In certain embodiments, the rate of swelling ofthe plasticized PVA diverter material also may increase as the size ofthe plasticized PVA diverter material decreases and as the ionicstrength of the carrier fluid decreases.

In certain embodiments, the plasticized PVA diverter material may beintroduced into a subterranean formation in an effective amount forplugging or partially plugging a permeable zone in the subterraneanformation. In certain embodiments, the plasticized PVA diverter materialand/or a fluid comprising a plasticized PVA diverter material may atleast partially plug off a permeable zone of the subterranean formation,thereby diverting at least a portion of a fluid to less permeablesections of the formation. In some embodiments, the plasticized PVAdiverter material may plug or bridge a substantial portion of apermeable zone of the subterranean formation. In certain embodiments,the plasticized PVA diverter material may at least partially bridge apermeable zone. In some embodiments, the plasticized PVA divertermaterial may divert a fluid so as to obtain a uniform distribution ofthose fluids throughout the subterranean formation regardless of thepermeability of the particular portion thereof. In certain embodiments,the plasticized PVA diverter material may divert fluids away fromcertain portions (e.g., water-producing portions) of a subterraneanformation entirely to treat other portions (e.g., hydrocarbon-producingportions) of the subterranean formation.

In certain embodiments, the plasticized PVA diverter material mayundergo dissolution downhole. In certain embodiments, the plasticizedPVA diverter material may at least partially dissolve so as to allowincreased flow of produced fluids that comprise hydrocarbons from thepermeable zone into the wellbore. In certain embodiments, at least aportion of the plasticized PVA diverter material may dissolve intoliquid that may be produced back to the surface. In certain embodiments,the dissolution products of the plasticized PVA diverter material have apH that is about neutral. In some embodiments, the dissolution productsof the plasticized diverter material have a pH from about 6 to about 8.In certain embodiments, once dissolved, the plasticized PVA divertermaterial may be removed from the permeable zone to at least partiallyunplug the permeable zone without performing any secondary cleanupoperations. In certain embodiments, the dissolution of the plasticizedPVA diverter material of the present disclosure may occur over a periodof time under downhole conditions as a result of the subterraneanenvironment (e, g., temperature, pressure, pH, water content, etc.). Incertain embodiments, the first diverter material may at least partiallydissolve.

In certain embodiments, dissolution of the plasticized PVA divertermaterial of the present disclosure may occur at a downhole temperatureof the subterranean formation of from about room temperature to about350° F. In other embodiments, dissolution of the plasticized PVAdiverter material of the present disclosure may occur at a downholetemperature of the subterranean formation of about 110° F. or lower,about 120° F. or lower, about 130° F. or lower, or about 140° F. orlower. In some embodiments, dissolution of the plasticized PVA divertermaterial of the present disclosure may occur at a downhole temperatureof the subterranean formation from about 110° F. to about 140° F., fromabout room temperature to about 350° F., from about room temperature toabout 140° F., from about room temperature to about 130° F., from about110° F. to about 130° F., from about 80° F. to about 200° F., or fromabout 100° F. to about 130° F. In certain embodiments, dissolution ofthe plasticized PVA diverter material may occur at a downholetemperature of the subterranean formation around about 110° F.

In certain embodiments, the time period over which substantialdissolution of the plasticized PVA diverter material occurs may vary. Insome embodiments, the time period over which dissolution occurs maydepend on the downhole temperature of the subterranean formation. Incertain embodiments, the rate at which dissolution of the plasticizedPVA diverter material occurs may increase as the downhole temperature ofthe subterranean formation increases. In certain embodiments,dissolution of the plasticized PVA diverter material of the presentdisclosure may occur over a time period of from about 24 hours to about14 days. In other embodiments, the dissolution of the plasticized PVAdiverter material of the present disclosure may occur over a time periodof from about 24 hours to about 168 hours, from about 1 day to about 7days, from about 1 day to about 14 days, or from about 6 days to about 7days. In some embodiments, dissolution of the plasticized PVA divertermaterial of the present disclosure may occur over a time period of lessthan about 14 days or less than about 7 days. In other embodiments,dissolution of the plasticized PVA diverter material of the presentdisclosure may occur over a time period of less than 24 hours. Incertain embodiments, a crosslinking agent may be combined with theplasticized PVA diverter material before being introduced into thesubterranean formation to delay the dissolution of the plasticized PVAdiverter material. In some embodiments, a borate crosslinking agent maybe combined with the plasticized PVA diverter material before beingintroduced into the subterranean formation.

According to some embodiments, the plasticized PVA diverter material maybe combined with a carrier fluid to form a treatment fluid before beingintroduced into a subterranean formation. In certain embodiments, thecarrier fluid may be used to introduce the plasticized PVA divertermaterial into or adjacent to a permeable zone of the subterraneanformation using one or more pumps. The carrier fluid may be any suitablefluid for moving the plasticized PVA diverter material to desiredlocations in the subterranean formation. In certain embodiments, thecarrier fluid may be an aqueous base fluid. The aqueous base fluids usedin accordance with the present disclosure may comprise water from anysource. Examples of aqueous base fluids with which the plasticized PVAdiverter material may be combined in certain embodiments of the presentdisclosure include, but are not limited to, fresh water, salt water (e.g., water containing one or more salts dissolved therein), deionizedwater, brine water of varying salinity, seawater and any combinationthereof.

In certain embodiments, the aqueous base fluid may be used to introducethe plasticized PVA diverter material into or adjacent to a permeablezone of the subterranean formation. In certain embodiments, the aqueousbase fluid may be mixed with the plasticized PVA diverter material priorto introduction into the subterranean formation. In certain embodiments,the aqueous base fluid may be introduced into the subterranean formationto contact the plasticized PVA diverter material. In certainembodiments, the amount of aqueous base fluid introduced into thesubterraneous may be an effective amount for dissolving the plasticizedPVA diverter material. In such embodiments, the plasticized PVA divertermaterial may be introduced into the aqueous base fluid as the aqueousbase fluid is being pumped into the wellbore to prevent prematureswelling, degradation, or dissolution of the plasticized PVA divertermaterial. In certain embodiments, the aqueous base fluid may beintroduced into the subterranean formation before the plasticized PVAdiverter material is introduced.

In certain embodiments, the aqueous base fluid may be of the type thatinhibits the swelling of the plasticized PVA diverter material (e.g.,calcium chloride brines). In certain embodiments, the salinity of theaqueous base fluid may be increased to reduce the rate at which theplasticized PVA diverter material swells or degrades. In otherembodiments, a non-aqueous base fluid may be used to introduce theplasticized PVA diverter material into or adjacent to a permeable zoneof the subterranean formation. In such embodiments, the plasticized PVAdiverter material will not degrade in the non-aqueous carrier fluid sothe plasticized PVA diverter material may be combined with the basefluid before being introduced into the wellbore.

As would be appreciated by those of ordinary skill in the art with thebenefit of this disclosure, the effective amount of plasticized PVAdiverter material may vary depending on factors such as the type of thecarrier fluid, the size of a fracture, fissure, and the like. In certainembodiments, the carrier fluid may comprise the plasticized PVA divertermaterial in an amount from about 0.01 to about 5.5 pounds of plasticizedPVA diverter material per gallon of carrier fluid (ppg). In otherembodiments, the carrier fluid may contain the plasticized PVA divertermaterial in an amount from about 0.01 ppg to about 5 ppg, from about0.01 ppg to about 4.5 ppg, from about 0.01 ppg to about 4.0 ppg, fromabout 0.01 ppg to about 3.5 ppg, from about 0.01 ppg to about 3.0 ppg,from about 0.01 ppg to about 2.5 ppg, from about 0.01 ppg to about 2.0ppg, from about 0.01 ppg to about 1.5 ppg, from about 0.01 ppg to about1.0 ppg, and from about 0.01 ppg to about 0.5 ppg. In certainembodiments, the carrier fluid may comprise the plasticized PVA divertermaterial in an amount greater than 0.01, 0.1, 0.5, 1, 1.5, 2, 2.5, 3,3.5, 4, 4.5, or 5 ppg. In some embodiments, the carrier fluid maycomprise the plasticized PVA diverter material in an amount less than5.5, 5.0, 4.5, 4, 3.5, 3, 2.5, 2, 1.5, 1, 0.5, or 0.1 ppg. In certainembodiments, the carrier fluid containing the plasticized PVA divertermaterial may remain sufficiently non-viscous in order to allow it to beplaced in the permeable areas of the subterranean formation. Thus, theremay be no need to apply higher pressure that could damage the rockstructure surrounding the subterranean formation in an attempt to forcethe plasticized PVA diverter material into the permeable areas.

In certain embodiments, a treatment fluid may be introduced into thesubterranean formation and diverted by the plasticized PVA divertermaterial of the present disclosure. The treatment fluids that may beuseful in accordance with the present disclosure may be used to carryout a variety of subterranean treatments, including, but not limited tohydraulic fracturing treatments, acidizing treatments, and drillingoperations. The treatment fluids of the present disclosure may be usedin treating a portion of a subterranean formation, for example, inacidizing treatments such as matrix acidizing or fracture acidizing.Acidizing and fracturing procedures using acidic treatment fluids may becarried out in subterranean formations to accomplish a number ofpurposes including, but not limited to, to facilitate the recovery ofdesirable hydrocarbons from the formation.

Depending on the type of treatment to be performed, the treatment fluidmay comprise any treatment fluid known in the art. Treatment fluids thatmay be useful in accordance with the present disclosure include, but arenot limited to, fracturing fluids, gravel packing fluids, pre-padfluids, pad fluids, preflush fluids, afterflush fluids, acidic fluids,consolidation fluids, cementing fluids, wellbore clean-out fluids,conformance fluids, aqueous fluids (e.g., fresh water, salt water,brines, etc.), non-aqueous fluids (e.g., mineral oils, synthetic oils,esters, etc.), hydrocarbon-based fluids (e.g., kerosene, xylene,toluene, diesel, oils, etc.), foamed fluids (e.g., a liquid thatcomprises a gas), gels, emulsions, gases, and the like.

The treatment fluids that may be useful in accordance with the presentdisclosure may comprise any base fluid known in the art, including, butnot limited to, aqueous fluids, non-aqueous fluids, and any combinationsthereof. In certain embodiments, the pH of the aqueous fluid may beadjusted (e.g., by a buffer or other pH adjusting agent) to a specificlevel, which may depend on, among other factors, the types ofviscosifying agents, acids, and other additives included in the fluid.One of ordinary skill in the art with the benefit of this disclosurewill recognize when such density and/or pH adjustments are appropriate.Examples of non-aqueous fluids that may be suitable for use in themethods of the present disclosure include, but are not limited to, oils,hydrocarbons, organic liquids, and the like. In certain embodiments, thetreatment fluids may comprise a mixture of one or more fluids and/orgases, including but not limited to emulsions, foams, and the like.

In certain embodiments, the treatment fluids and/or carrier fluids usedin the methods of the present disclosure optionally may comprise anynumber of additional additives. Examples of such additional additivesinclude, but are not limited to, salts, surfactants, acids, chelatingagents, proppant particulates, microproppant particulates, additionaldiverter materials, fluid loss control additives, gas, nitrogen, carbondioxide, surface modifying agents, tackifying agents, foamers, corrosioninhibitors, scale inhibitors, catalysts, clay control agents, biocides,friction reducers, antifoam agents, bridging agents, flocculants, H₂Sscavengers, CO₂ scavengers, oxygen scavengers, lubricants, additionalviscosifiers, breakers, weighting agents, relative permeabilitymodifiers, resins, wetting agents, coating enhancement agents, filtercake removal agents, antifreeze agents (e.g., ethylene glycol), and thelike. In certain embodiments, one or more of these additional additives(e.g., a crosslinking agent) may be added to a treatment fluid and/orcarrier fluid. A person skilled in the art with the benefit of thisdisclosure will recognize the types of additives that may be included inthe fluids of the present disclosure for a particular application.

In certain embodiments, additional diverter materials may be introducedinto the subterranean formation. Any suitable diverter material known inthe art may be used along with the plasticized PVA diverter material. Incertain embodiments, the methods of the present disclosure may compriseintroducing a second diverter material into or adjacent to a permeablezone of a subterranean formation. In certain embodiments, the seconddiverter material may be introduced into the same portion of thesubterranean formation as the first diverter material. In someembodiments, the second diverter material may be introduced into adifferent portion of the subterranean formation as the first divertermaterial. In some embodiments, a diverter composition may comprise aplasticized PVA diverter material and a second diverter material. Anysuitable diverting agent may be used as the second diverter material.Second diverter materials suitable for certain embodiments of thepresent disclosure include polyvinyl alcohol, calcium carbonate,polyglycolic acid, polylactic acid, and any combination thereof. In someembodiments, the second diverter material may comprise PVA. In someembodiments, the second diverter material may consist essentially ofPVA. In certain embodiments, the second diverter material may notcomprise a substantial amount of a plasticizer. In some embodiments, thesecond diverter material consists essentially of PVA.

The second diverter material may be introduced prior to, concurrentlywith, and/or subsequent to the introduction of the plasticized PVAdiverter material. In certain embodiments, the second diverter materialmay be introduced in the same carrier fluid as the plasticized PVAdiverter material or in a different carrier fluid. In some embodiments,the second diverter material may at least partially divert fluid to adifferent portion of the subterranean formation. In certain embodiments,the second diverter material may plug or partially plug a permeablezone. In some embodiments, the second diverter material may degrade inthe formation. In certain embodiments, the second diverter material mayat least partially degrade in the formation. In certain embodiments, thesecond diverter material may degrade into liquid that may be producedback to the surface. In certain embodiments, the degradation products ofthe second diverter material have a pH that is about neutral. In certainembodiments, once degraded, the second diverter material may be removedfrom the permeable zone to at least partially unplug the permeable zonewithout performing any secondary cleanup operations. In certainembodiments, the degradation of the second diverter material of thepresent disclosure may occur over a period of time under downholeconditions as a result of the subterranean environment (e.g.,temperature, pressure, pH, water content, etc.).

In certain embodiments, the second diverter material may be in aparticulate form. In some embodiments, the second diverter material maycomprise particles from about 1 micron to about 3400 microns or fromabout 1 micron to about 2000 microns. In certain embodiments, the seconddiverter material may comprise particles with a diameter of less than3400, 3000, 2500, 2000, 1500, 1000, 500, 400, 300, 200, or 100 microns.In certain embodiments, the second diverter material may compriseparticles with a diameter of less than 2000 microns. In someembodiments, the second diverter material may comprise particles of U.S.mesh size 6 or smaller. In some embodiments, the size of the seconddiverter material particles may be U.S. mesh size 8 or smaller. An upperlimit of the size of second diverter material particles according tovarious embodiments may be any one of: 80, 70, 60, 50, 40, 35, 30, 25,20, 18, 16, 14, 12, 10, 8, 7, 6, and 4 U.S. mesh size. In certainembodiments, the second diverter material may be sized in any one ormore of the following size ranges: about 6 to about 100 U.S. mesh; about6 to about 140 U.S. mesh; about 10 to about 100 U.S. mesh; about 10 toabout 140 U.S. mesh; about 6 to about 400 U.S. mesh; about 6 to about400 U.S. mesh; about 10 to about 400 U.S. mesh; and about 10 to about400 U.S. mesh. In some embodiments, the first diverter materialcomprises particles larger than the second diverter material. In certainembodiments, the first diverter material comprises particlessubstantially larger than the second diverter material.

Examples of commercially available PVA particles suitable for certainembodiments of the present disclosure include, but are not limited toSelvol™ 103 and 425 (available from Sekisui Specialty Chemicals, Dallas,Tex.) and Kurary Poval® 3-98 (available from Kuraray America Inc.,Houston, Tex.).

In some embodiments, a diverter composition comprises a first divertermaterial and a second diverter material. In certain embodiments, adiverter composition may be mixed with a carrier fluid prior tointroduction into the permeable zone. In certain embodiments, thecarrier fluid may comprise the diverter composition in an amount fromabout 0.01 to about 5.5 pounds of diverter composition per gallon ofcarrier fluid (ppg). In other embodiments, the carrier fluid may containthe diverter composition in an amount from about 0.01 ppg to about 5ppg, from about 0.01 ppg to about 4.5 ppg, from about 0.01 ppg to about4.0 ppg, from about 0.01 ppg to about 3.5 ppg, from about 0.01 ppg toabout 3.0 ppg, from about 0.01 ppg to about 2.5 ppg, from about 0.01 ppgto about 2.0 ppg, from about 0.01 ppg to about 1.5 ppg, from about 0.01ppg to about 1.0 ppg, from about 0.01 ppg to about 0.5 ppg. In certainembodiments, the carrier fluid may comprise the diverter composition inan amount greater than 0.01, 0.1, 0.5, 1, 1.5, 2, 2.5, 3, 3.5, 4, 4.5,or 5 ppg. In some embodiments, the carrier fluid may comprise thediverter composition in an amount less than 5.5, 5.0, 4.5, 4, 3.5, 3,2.5, 2, 1.5, 1, 0.5, or 0.1 ppg.

In certain embodiments, the plasticized PVA diverter material maycomprise from about 0.1 to about 100% by weight of the divertercomposition. In some embodiments, the second diverter material maycomprise from about 0.1 to about 100% by weight of the divertercomposition. The ratio of plasticized PVA diverter material to thesecond diverter material in the diverter composition may, in certainembodiments, be about 10:90, 20:80, 30:70, 40:60, 50:50, 60:40, 70:30,80:20, or 90:10. In some embodiments, the diverter composition comprisesabout 35 percent plasticized PVA diverter material.

In some embodiments, the present disclosure provides methods and systemsthat may be used in carrying out a variety of subterranean operations,including, but not limited to drilling operations, workover operations,cementing operations, completions operations, stimulation operations(e.g., hydraulic fracturing treatments or acidizing treatments),wellbore clean-up operations, and the like. The methods and systems ofthe present disclosure also may be used during periods when hydrocarbonsor other fluids are being produced from a subterranean formation and/orwellbore. The wellbores in which the methods and systems of the presentdisclosure may be used may be cased holes or open holes, as well aspartially cased or partially open holes. The wellbores also may bevertical wellbores or may comprise portions that are deviated orhorizontal to any degree.

In certain embodiments, stages of diverter compositions comprisingplasticized PVA diverter material may be introduced into a subterraneanformation in the course of fracturing and/or re-fracturing treatments incertain regions or zones in the formation, among other reasons, toselectively treat certain regions and/or facilitate more uniformstimulation of different regions of the formation having differentpermeabilities.

In other embodiments, a diverter composition comprising plasticized PVAdiverter material may be introduced into other regions of a formation(e.g., other than perforations in a wellbore casing) to form a plugtherein. Such plugs comprising plasticized PVA diverter material mayisolate a particular portion of a wellbore or subterranean formation,among other reasons, in order to allow for selective treatment of otherareas, or to prevent the flow of fluids from one area of a formation toanother. These plugs may be useful in many different types ofsubterranean operations, including those listed above.

For example, and with reference to FIG. 1 , the disclosed methods maydirectly or indirectly affect one or more components or pieces ofequipment associated with a stimulation system 10, according to one ormore embodiments. In certain embodiments, the system 10 includes a fluidproducing apparatus 20, a fluid source 30, a diverter composition source40, and a pump and blender system 50 and resides at the surface at awell site where a well 60 is located. The fluid can be a fluid for readyuse in a treatment of the well 60. In other embodiments, the fluidproducing apparatus 20 may be omitted and the fluid sourced directlyfrom the fluid source 30.

The diverter composition source 40 can include a diverter compositionfor combination with a fluid. The system 10 may also include additivesource 70 that provides one or more additives (e.g., bridging agents,gelling agents, weighting agents, and/or other optional additives) toalter the properties of the fluid. For example, the other additives 70can be included to reduce pumping friction, to reduce or eliminate thefluid's reaction to the geological formation in which the well isformed, to operate as surfactants, and/or to serve other functions. Insome embodiments, the plasticized PVA diverter material of the presentdisclosure may be introduced into a fluid via the diverter compositionsource 40 or the additive source 70.

The pump and blender system 50 may receive the fluid and combine it withother components, including a diverter composition from the divertercomposition source 40 and/or additional components from the additivessource 70. In certain embodiments, the resulting mixture may be pumpeddown the well 60 at a pressure suitable to introduce the fluid into oneor more permeable zones in the subterranean formation. In certaininstances, the fluid producing apparatus 20, fluid source 30, and/ordiverter composition source 40 may be equipped with one or more meteringdevices or sensors (not shown) to control and/or measure the flow offluids, proppants, diverters, bridging agents, and/or other compositionsto the pumping and blender system 50. In certain embodiments, themetering devices may permit the pumping and blender system 50 to sourcefrom one, some, or all of the different sources at a given time, and mayfacilitate the preparation of fluids in accordance with the presentdisclosure using continuous mixing or “on-the-fly” methods. Thus, forexample, the pumping and blender system 50 can provide just fluid intothe well at some times, just additives at other times, and combinationsof those components at yet other times.

While not specifically illustrated herein, the disclosed methods andsystems may also directly or indirectly affect any transport or deliveryequipment used to convey wellbore compositions to the system 50 such as,for example, any transport vessels, conduits, pipelines, trucks,tubulars, and/or pipes used to fluidically move compositions from onelocation to another, any pumps, compressors, or motors used to drive thecompositions into motion, any valves or related joints used to regulatethe pressure or flow rate of the compositions, and any sensors (e.g.,pressure and temperature), gauges, and/or combinations thereof, and thelike.

FIG. 2 shows a side view of a subterranean formation penetrated by awellbore with a casing string 80 placed in the wellbore. The wellborepenetrates two zones 90 and 100 in the subterranean formation, whereinthe fluid flow resistance of zone 90 is higher than the fluid flowresistance of zone 100. Perforations 82, 84 have been created in thecasing string 80 to allow for fluid flow into the zones 90 and 100. Incertain embodiments, a plasticized PVA diverter material 88 of thepresent disclosure may be introduced into at least a portion of theperforations 82 within zone 100 or adjacent to a least a portion of zone100 of the subterranean formation using one or more pumps. Once theplasticized PVA diverter material 88 is introduced into the subterraneanformation, an aqueous fluid may be introduced into the subterraneanformation to contact the plasticized PVA diverter material 88. Incertain embodiments, the introduction of the plasticized PVA divertermaterial 88 and the introduction of the aqueous fluid may be reversedsuch that the aqueous fluid is first introduced into at least a portionof zone 100 followed by the plasticized PVA diverter material 88. Inother embodiments, the aqueous base fluid may be a carrier fluid suchthat the plasticized PVA diverter material 88 and the aqueous fluid areintroduced into at least a portion of zone 90 simultaneously.

Once introduced into the wellbore, the plasticized PVA diverter material88 may plug or partially plug zone 100. A treatment fluid 86 may then beintroduced into the wellbore and diverted by the plug or partial plug ofthe plasticized PVA diverter material 88 to the less permeable zone 90of the subterranean formation. The treatment fluid 86 may be allowed tointeract with the less permeable zone 90 of the subterranean formation.

After diverting the treatment fluid, the plug or partial plug of theplasticized PVA diverter material 88 may degrade over time at anaturally occurring downhole temperature of the subterranean to at leastpartially unplug zone 100 without having to perform secondary cleanupoperations. In another embodiment, this diverting procedure may berepeated with respect to each of a second, third, fourth, or more,treatment stages to divert the treatment fluid to further less permeablezones of the subterranean formation.

Additives may be incorporated into the diverter compositions of variousembodiments by any suitable means. For example, additives may be dryblended with the diverter composition before the addition of a fluidsuch as water, by mixing with the fluid to be added to the divertercomposition, or by mixing with the diverter composition consecutivelywith, or after, the addition of the fluid. In some embodiments,additives may be pre-suspended in water and injected into the divertercomposition fluid or into the diverter composition slurry as an aqueousslurry. In certain embodiments, liquid additives (or suspendedadditives, as noted) may be mixed with a fluid such as water; solidadditives may be mixed with the diverter composition; and then the fluidand diverter composition (plus respective additives mixed therewith) maybe mixed together to form a pumpable slurry. Examples of liquidadditives suitable in certain embodiments of the present disclosure mayinclude set retarders, accelerants, surfactants, fluid loss controladditives, and dispersants. In some embodiments, any one or more ofthese liquid additives may be employed in solid form instead of or inaddition to their liquid form. Further examples of solid additives mayinclude rubber particles, carbon fibers, microspheres, and weightingmaterials.

The diverter compositions, diverter materials, and fluids of the presentdisclosure may be prepared using any suitable method and/or equipment(e.g., blenders, mixers, stirrers, etc.) known in the art at any timeprior to their use. The diverter compositions may be prepared at leastin part at a well site or at an offsite location. In certainembodiments, the aqueous base fluid may be mixed with the plasticizedPVA diverter material, and/or other components at a well site where theoperation or treatment is conducted, either by batch mixing orcontinuous (“on-the-fly”) mixing. The term “on-the-fly” is used hereinto include methods of combining two or more components wherein a flowingstream of one element is continuously introduced into a flowing streamof another component so that the streams are combined and mixed whilecontinuing to flow as a single stream as part of the on-going treatment.Such mixing can also be described as “real-time” mixing. In otherembodiments, the diverter compositions, plasticized PVA divertermaterials, and fluids of the present disclosure may be prepared, eitherin whole or in part, at an offsite location and transported to the sitewhere the treatment or operation is conducted. In introducing a fluid ordiverter material into a portion of a subterranean formation, thecomponents may be mixed together at the surface and introduced into theformation together, or one or more components may be introduced into theformation at the surface separately from other components such that thecomponents mix or intermingle in a portion of the formation to form atreatment fluid. In either such case, the treatment fluid is deemed tobe introduced into at least a portion of the subterranean formation forpurposes of the present disclosure.

The exemplary diverter compositions and diverter materials disclosedherein may directly or indirectly affect one or more components orpieces of equipment associated with the preparation, delivery,recapture, recycling, reuse, and/or disposal of the disclosed divertercompositions and materials. For example, the disclosed compositions maydirectly or indirectly affect one or more mixers, related mixingequipment, mud pits, storage facilities or units, compositionseparators, heat exchangers, sensors, gauges, pumps, compressors, andthe like used generate, store, monitor, regulate, and/or recondition thecompositions. The disclosed compositions may also directly or indirectlyaffect the various downhole equipment and tools that may come intocontact with the cement compositions/additives such as, but not limitedto, wellbore casing, wellbore liner, completion string, insert strings,drill string, coiled tubing, slickline, wireline, drill pipe, drillcollars, mud motors, downhole motors and/or pumps, cement pumps,surface-mounted motors and/or pumps, centralizers, turbolizers,scratchers, floats (e.g., shoes, collars, valves, etc.), logging toolsand related telemetry equipment, actuators (e.g., electromechanicaldevices, hydromechanical devices, etc.), sliding sleeves, productionsleeves, plugs, screens, filters, flow control devices (e.g., inflowcontrol devices, autonomous inflow control devices, outflow controldevices, etc.), couplings (e.g., electro-hydraulic wet connect, dryconnect, inductive coupler, etc.), control lines (e.g., electrical,fiber optic, hydraulic, etc.), surveillance lines, drill bits andreamers, sensors or distributed sensors, downhole heat exchangers,valves and corresponding actuation devices, tool seals, packers, cementplugs, bridge plugs, and other wellbore isolation devices, orcomponents, and the like.

To facilitate a better understanding of the present disclosure, thefollowing examples of certain aspects of preferred embodiments aregiven. The following examples are not the only examples that could begiven according to the present disclosure and are not intended to limitthe scope of the disclosure or claims.

EXAMPLES Example 1

The following example demonstrates the degradability of a plasticizedPVA diverter material (Selvol™ 103 with plasticizer and Selvol™ 425 withplasticizer) over time compared to other diverter materials (apolylactic acid (“PLA”) diverter material, and Selvol™ 103 without aplasticizer). The plasticized PVA diverter materials were cylindricalbeads with a size of from about 4 to about 6 U.S. mesh. Thenon-plasticized Selvol™ 103 had a particle size distribution of about 16mesh and smaller. The PLA diverter material, FDP-S1248-16, had amulti-modal particle size distribution ranging from 100 to 3400 microns.

To start, 0.5 grams of each diverter material was added to 100 mL ofHouston tap water. The mixtures were then placed in a heated water bathat 110° F. and allowed to age. After seven days (168 hours), thediverter material was filtered, rinsed, and placed in a 160° F. ovenovernight. The dried sample was weighed and a mass balance wascalculated based on the starting mass to determine the amount of weightloss. The results are shown in Table 1.

TABLE 1 Mass in 100 mL Temp Material of Tap Water (g) (° F.) Hours %Degraded FDP-S1248-16 0.5 110 168 9 Selvol ™ 103 0.5 110 168 44 Selvol ™103 Beads 0.5 110 168 66 with plasticizer Selvol ™ 425 Beads 0.5 110 16867 with plasticizer

As shown in Table 1, the plasticized PVA diverter materials (Selvol™ 103with plasticizer and Selvol™ 425 with plasticizer) displayed a morerapid degradation profile over 7 days than the non-plasticized PVA of asmaller particle size (Selvol™ 103) and the PLA diverter material.Without being limited by theory, the faster degradation rate of theplasticized PVA may be attributed to the increased water solubility ofthe plasticizer.

Example 2

The following example shows the diversion performance of a divertercomposition comprising 10% plasticized Selvol™ 103 PVA diverter materialand 90% non-plasticized PVA (Kuraray Poval® 3-98 PVA) compared to thediversion performance of a PLA diverter material (FDP-S1248-16). Theplasticized Selvol™ 103 was cylindrical beads with a size of from about4 to about 6 U.S. mesh. The non-plasticized PVA (Kuraray Poval® 3-98PVA) had a particle size distribution of about 16 mesh and smaller. ThePLA diverter material, FDP-S1248-16, had a multi-modal particle sizedistribution ranging from 100 to 3400 microns.

A FANN HPHT Filter Press apparatus was used to measure diversionperformance in a 2032 μm slot. The cell was pre-warmed to the testingtemperature (130° F.) and loaded with each diverter material. Thediverter material was suspended in a 30# WG-38 (diutan) fluid tominimize particle settling during fluid heating times and during thetest. The fluid loss test was initiated and displacement fluid (colordyed 30# WG-38) was pumped with an ISCO dual piston pump set to constantpressure flow regime with a set rate limit of 24 mL/min. Pressure (psi)and pump rate (mL/min) were measured as a function of time. The test wasrun until either 500 psi was achieved and the pump rate dropped to lessthan 1 mL/min or the colored dye was noted in the effluent.

FIGS. 3 and 4 show the results. As shown in FIGS. 3 and 4 , the divertercomposition comprising plasticized PVA diverter material, even at a 10%bead loading, in combination with a commercial PVA, out-performed thePLA divertering material, FDP-S1248-16, which contains about 35% beads.This demonstrates the efficacy of a plasticized PVA for sealing off aslot/fracture, and emphasizes the importance of large particles forinitiating bridging of the slot.

An embodiment of the present disclosure is a method comprising:introducing a first diverter material comprising polyvinyl alcohol and aplasticizer into or adjacent to a permeable zone of a subterraneanformation; introducing a second diverter material into or adjacent tothe permeable zone of the subterranean formation, wherein at least aportion of the first diverter material comprises particles larger thanparticles of the second diverter material; and allowing the firstdiverter material and the second diverter material to at least partiallydivert at least a portion of a treatment fluid to a different portion ofthe subterranean formation.

Another embodiment of the present disclosure is a method comprising:introducing a first treatment fluid comprising an aqueous base fluid anda first diverter material comprising polyvinyl alcohol and a plasticizerinto or adjacent to a permeable zone of a subterranean formation,wherein the first diverter material comprises particles sized 6 U.S.mesh or larger; and allowing the first treatment fluid to at leastpartially divert at least a portion of a second treatment fluid to adifferent portion of the subterranean formation.

Another embodiment of the present disclosure is a method comprising:introducing a first diverter composition into or adjacent to a permeablezone of a subterranean formation, wherein the first diverter compositioncomprises: a first diverter material comprising polyvinyl alcohol and aplasticizer, wherein the first diverter material comprises particlessized 6 U.S. mesh or larger; and a second diverter material comprisingparticles sized 8 U.S. mesh or smaller; and allowing the divertercomposition to at least partially divert at least a portion of atreatment fluid to a different portion of the subterranean formation.

Therefore, the present disclosure is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent disclosure may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. While numerous changes may be made bythose skilled in the art, such changes are encompassed within the spiritof the subject matter defined by the appended claims. Furthermore, nolimitations are intended to the details of construction or design hereinshown, other than as described in the claims below. It is thereforeevident that the particular illustrative embodiments disclosed above maybe altered or modified and all such variations are considered within thescope and spirit of the present disclosure. In particular, every rangeof values (e.g., “from about a to about b,” or, equivalently, “fromapproximately a to b,” or, equivalently, “from approximately a-b”)disclosed herein is to be understood as referring to the power set (theset of all subsets) of the respective range of values. The terms in theclaims have their plain, ordinary meaning unless otherwise explicitlyand clearly defined by the patentee.

What is claimed is:
 1. A method comprising: introducing a treatmentfluid comprising a diverter material into a permeable zone of asubterranean formation, wherein the diverter material comprises acomposite material of a polyvinyl alcohol and a plasticizer, wherein thediverter material comprises particles having a particle sizedistribution of about 2 to about 10 U.S. mesh, and wherein the permeablezone is part of a wellbore that is permeated or penetrated by fracturesand fissures; and allowing the diverter material to at least partiallydivert at least a portion of a treatment fluid to a different portion ofthe subterranean formation.
 2. The method of claim 1, wherein thediverter material is introduced using one or more pumps.
 3. The methodof claim 1, wherein the treatment fluid further comprises a carrierfluid.
 4. The method of claim 2, wherein the carrier fluid comprises atleast one carrier fluid selected from the group consisting of freshwater, salt water, deionized water, brine water, seawater, and anycombination thereof.
 5. The method of claim 1, wherein the plasticizercomprises at least one plasticizer selected from the group consisting ofglycol, polyethylene glycol, polypropylene glycol, a fatty acid ester, aglycolide monomer, a citric acid ester, epoxidized oil, adipate ester,azaleate ester, acetylated coconut oil, and any combination thereof. 6.The method of claim 1, wherein the diverter material has an aspect ratioof 20:1 or less.
 7. The method of claim 1, wherein the diverter materialhas a particle size distribution of about 4 to about 8 U.S. mesh.
 8. Themethod of claim 1, wherein a shape of the diverter material comprises atleast one shape selected from the group consisting of platelets,shavings, flakes, ribbons, rods, strips, spheroids, toroids, stars,sheets, cylinders, beads, cylindrical beads, cubes, pellets, tablets,any other physical shape, and any combination thereof.
 9. The method ofclaim 1, wherein the shape of the diverter material comprisescylindrical particles.
 10. The method of claim 1, further comprisingallowing the diverter material to at least partially dissolve.
 11. Amethod comprising: introducing a treatment fluid comprising a divertermaterial into a permeable zone of a subterranean formation, wherein thediverter material comprises a composite material of a polyvinyl alcoholand a plasticizer, wherein the diverter material comprises particleshaving an aspect ratio of 20:1 or less, and wherein the permeable zoneis part of a wellbore that is permeated or penetrated by fractures andfissures; and allowing the diverter material to at least partiallydivert at least a portion of a treatment fluid to a different portion ofthe subterranean formation.
 12. The method of claim 11, wherein thediverter material is introduced using one or more pumps.
 13. The methodof claim 11, wherein the treatment fluid further comprises a carrierfluid.
 14. The method of claim 11, wherein the plasticizer comprises atleast one plasticizer selected from the group consisting of glycol,polyethylene glycol, polypropylene glycol, a fatty acid ester, aglycolide monomer, a citric acid ester, epoxidized oil, adipate ester,azaleate ester, acetylated coconut oil, and any combination thereof. 15.The method of claim 11, wherein the diverter material has a particlesize distribution of about 4 to 8 U.S. mesh.
 16. The method of claim 11wherein a shape of the diverter material comprises at least one shapeselected from the group consisting of platelets, shavings, flakes,ribbons, rods, strips, spheroids, toroids, stars, sheets, cylinders,beads, cylindrical beads, cubes, pellets, tablets, any other physicalshape, and any combination thereof.
 17. The method of claim 11, furthercomprising allowing the diverter material to at least partiallydissolve.
 18. A wellbore treatment fluid comprising: an aqueous carrierfluid; and a diverter material, wherein the diverter comprises acomposite material of a polyvinyl alcohol and a plasticizer, wherein thediverter material comprises particles having a particle sizedistribution of about 2 to about 10 U.S. mesh, and wherein the divertermaterial comprises particles having an aspect ratio of 20:1 or less. 19.The wellbore treatment fluid of claim 18, wherein the aqueous carrierfluid comprises at least one aqueous carrier fluid selected from thegroup consisting of fresh water, salt water, deionized water, brinewater, seawater, and any combination thereof.
 20. The wellbore treatmentfluid of claim 18, wherein the diverter material is present in thetreatment fluid in an amount from about 0.01 to about 5.5 pounds ofdiverter material per gallon of carrier fluid.